A frame for supporting a horizontal pumping system includes a base assembly and a motor support assembly connected to the base assembly. The motor support assembly includes an upper support plate having a top and a bottom, a first lower support plate connected to the upper support plate, and a second lower support plate connected to the upper support plate. The first and second lower support plates are connected to the upper plate with bolted and welded connections.

A frame for supporting a horizontal pumping system includes a base assembly and a motor support assembly connected to the base assembly. The motor support assembly includes an upper support plate having a top and a bottom, a first lower support plate connected to the upper support plate, and a second lower support plate connected to the upper support plate. The first and second lower support plates are connected to the upper plate with bolted and welded connections.

The present embodiments disclose a mechanical shaft lock for use in electric submersible pumps. The mechanical shaft lock can include one or more shear pins. When an end of the shear pin, e.g., shear pin head, lines up with one or more shearing slots on the MSL or pump shaft, the shear pin engages and stops the rotation of the pump shaft and motor attached to the pump. The shaft lock can be engaged for installing an ESP, disengaged for production after installing by breaking the shear pin upon start-up, and re-engaged for removing the ESP from the wellbore. In some embodiments, the MSL may be configured to be disengaged and re-engaged to deal with well kicks.

The present embodiments disclose a mechanical shaft lock for use in electric submersible pumps. The mechanical shaft lock can include one or more shear pins. When an end of the shear pin, e.g., shear pin head, lines up with one or more shearing slots on the MSL or pump shaft, the shear pin engages and stops the rotation of the pump shaft and motor attached to the pump. The shaft lock can be engaged for installing an ESP, disengaged for production after installing by breaking the shear pin upon start-up, and re-engaged for removing the ESP from the wellbore. In some embodiments, the MSL may be configured to be disengaged and re-engaged to deal with well kicks.

A double curvature blade for a portion of system. The system may include a pump, such as a submersible pump. The pump may include a multiple or single stage pump. The pump may be powered by a selected motor.

Systems and features for improving sand control in pumps are provided. These features can be used in centrifugal pumps employed in a variety of oilfield applications, such as in electric submersible pumping systems positioned downhole in a wellbore to pump oil or other fluids. Such features include shielded anti-swirl ribs positioned in the balance chamber.

Systems and features for improving sand control in pumps are provided. These features can be used in centrifugal pumps employed in a variety of oilfield applications, such as in electric submersible pumping systems positioned downhole in a wellbore to pump oil or other fluids. Such features include shielded anti-swirl ribs positioned in the balance chamber.

A thrust box with improved cooling comprises a case having an interior, a first passageway and an opposing second passageway. A shaft passes through the case and the first and second passageway. A thrust runner is secured to the shaft and a pump ring is attached to the thrust runner. Advantageously, the pump ring facilitates oil rate circulation and cooling among other benefits.

An electrical submersible pump assembly (ESP) has a centrifugal production pump with production pump stages. A gas separator upstream is from the production pump. A centrifugal charge pump is upstream from the gas separator. The charge pump has charge pump stages and a discharge that leads to an intake of the gas separator. Each of the production pump stages has a higher lifting capacity than each of the charge pump stages. The impellers of the production pump stages have vane exit angles greater than vane exit angles of the impellers of the charge pump stages.

An electrical submersible pump assembly (ESP) has a centrifugal production pump with production pump stages. A gas separator upstream is from the production pump. A centrifugal charge pump is upstream from the gas separator. The charge pump has charge pump stages and a discharge that leads to an intake of the gas separator. Each of the production pump stages has a higher lifting capacity than each of the charge pump stages. The impellers of the production pump stages have vane exit angles greater than vane exit angles of the impellers of the charge pump stages.